Understanding apiicp653 reading 2 650 selected reading

Understanding APIICP653 Reading 2 APIST650-Selected Reading BOK Referred Sections 2016 exam My Pre-exam Self Study Notes 27th October 2015

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Oil Terminal

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Petroleum Tank

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Petroleum Tanks

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API 653 Exam Administration -- Publications Effectivity Sheet FOR: November 2015, March 2016 and July 2016 Listed below are the effective editions of the publications required for this exam for the date(s) shown above.

API Recommended Practice 571, Damage Mechanisms Affecting Fixed Equipment in the Refining Industry, Second Edition, April 2011

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API 653 Exam Administration -- Publications Effectivity Sheet FOR: November 2015, March 2016 and July 2016 Listed below are the effective editions of the publications required for this exam for the date(s) shown above.

API Recommended Practice 571, Damage Mechanisms Affecting Fixed Equipment in the Refining Industry, Second Edition, April 2011

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ATTENTION: Only the following sections / mechanisms from RP 571 are included on the exam: Section 3, Definitions Par. 4.2.7 Brittle Fracture 4.2.16 Mechanical Fatigue 4.3.2 Atmospheric Corrosion 4.3.3 Corrosion Under insulation (CUI) 4.3.8 Microbiologically Induced Corrosion (MIC) 4.3.9 Soil Corrosion 4.3.10 Caustic Corrosion 4.5.1 Chloride Stress Corrosion Cracking (Cl-SCC) 4.5.3 Caustic Stress Corrosion Cracking (Caustic Embrittlement) 5.1.1.10 Sour Water Corrosion (Acidic) 5.1.1.11 Sulfuric Acid Corrosion

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• • • • • •

API Recommended Practice 575, Inspection of Atmospheric and LowPressure Storage Tanks, Third Edition, April 2014 API Recommended Practice 577 – Welding Inspection and Metallurgy, Second Edition, December 2013 API Standard 650, Welded Tanks for Oil Storage, Twelfth Edition, March 2013 with Addendum 1 (September 2014), Errata 1 (July 2013), and Errata 2 (December 2014).

API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks, Fourth Edition, September 2014.

API Recommended Practice 652, Lining of Aboveground Petroleum Storage Tank Bottoms, Fourth Edition, September 2014 API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction, Fifth Edition, November 2014.

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•

American Society of Mechanical Engineers (ASME), Boiler and Pressure Vessel Code, 2013 Edition i. ASME Section V, Nondestructive Examination, Articles 1, 2, 6, 7 and 23 (section SE-797 only) ii. Section IX, Welding and Brazing Qualifications (Welding Only)

See end of this study note for API Official BOK

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http://greekhouseoffonts.com/

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The Magical Book of Tank Inspection ICP

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闭门练功

API650-2013 BOK Search Keyword “650”

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REFERENCE PUBLICATIONS: A. API Publications • API Recommended Practice 571, Damage Mechanisms Affecting Equipment in Refining Industry • API Recommended Practice 575, Inspection of Atmospheric and LowPressure Storage Tanks • API Recommended Practice 577, Welding Inspection and Metallurgy • API Standard 650, Welded Steel Tanks for Oil Storage • API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks • API Recommended Practice 652, Lining of Aboveground Petroleum Storage Tank Bottoms • API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction

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I. CALCULATIONS & TABULAR EVALUATIONS FOR EVALUATING THICKNESS MEASUREMENTS, WELD SIZES, AND TANK INTEGRITY (NOTE: Paragraph references for all formulas and calculations listed here should be checked for accuracy to the edition, addenda, or supplement for the examination you plan to take per the Publication Effectivity Sheet in the API Examination Application.)

NOTE: Candidates are expected to be able to understand SI units (metric system) and the US customary units (inches, feet, PSI, etc.) and to use both system formulas.

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A. Calculation questions will be oriented toward existing tanks, not new tanks. API Authorized AST Inspectors should be able to check and perform calculations included in the following categories: 2. JOINT EFFICIENCIES The inspector must be able to determine the joint efficiency, "E", of a tank weld. Inspector should be able to determine: a) Joint Types (API-653 Section 4, Table 4-2) b) Type and extent of radiography performed (API 653, Table 4-2, Section 12; API 650, Section 8.1, Figure 8-1) c) Joint efficiency by reading API-653, Table 4-2 Determining joint efficiency may be part of a minimum thickness or maximum fill height problem since joint efficiency, "E", is used in the formulas for determining required thickness. (API-653, 4.3.3.1)

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4. WELD SIZES FOR SHELL & ROOF OPENINGS The inspector should be familiar with determining the sizes and spacing of welds for shell openings to the extent of being able to use the information in the following Figures and Tables: a) API-650, Figures 5-7a, 5-7b, 5-8, 5-9, 5-12, 5-14, 5-16, 5-17, 5-19, 5-20, 521 b) API-650, Tables 5-6, 5-7, 5-9 c) API-653, Figures 9-1, 9-2, 9-4, 9-5

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8. IMPACT TESTING The inspector should understand the importance of tank materials having adequate toughness. The inspector should be able to determine: a) Tank design metal temperature (API-650, 4.2.9.3 & Figure 4-2) b) Material Group Number for a plate (API-650, Tables 4-3a and 4-3b) c) If impact testing is required (API-650, Figure 4-1a and 4-1b) d) If impact test values are acceptable (API-650, Table 4-4a and 4-4b)

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10. RECONSTRUCTED TANK SHELL - MINIMUM THICKNESS The inspector should be able to determine the minimum thickness of the shell of a reconstructed tank. The inspector should be able to: a) Determine “Sd”, allowable stress for design condition (API-650, table 5-2, API-653, 8.4.2) b) Determine “St”, allowable stress for hydrostatic test condition (API-650, Table 5-2, API-653, 8.4.3) c) Calculate “td”, design shell thickness (API-650, 5.6.3.2, for tanks of 200 foot diameter and smaller) d) Calculate “tt”, hydrostatic test shell thickness (API-650, 5.6.3.2)

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II. WELDING ON ATMOSPHERIC ABOVEGROUND STORAGE TANKS ASME Section IX, Welding and Brazing Qualifications (NOTE: Candidates should be familiar with the basic requirements for welding qualifications for procedures and welding personnel contained in ASME Section IX. Brazing is NOT covered on the examination. ) A. The inspector should have the knowledge and skills required to review a Procedure Qualification Record and a Welding Procedure Specification or to answer questions requiring the same level of knowledge and skill. Questions covering the specific rules of Section IX will be limited in complexity and scope to the SMAW and SAW welding processes.

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A. The inspector should have the knowledge and skills required to review a Procedure Qualification Record and a Welding Procedure Specification or to answer questions requiring the same level of knowledge and skill. Questions covering the specific rules of Section IX will be limited in complexity and scope to the SMAW and SAW welding processes.

1. Questions will be based on: a) No more than one process b) Filler metals limited to one c) Essential, non-essential, variables only will be covered d) Number, type, and results of mechanical tests e) Base metals limited to P1 f) Additional essential variables required by API-650 or API-653

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C. API-650 and API-653: General welding requirements: 1. API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for welding in API-650, Section 9 and other rules for welding in API-650 such as those for: a) typical joints and definitions b) weld sizes c) restrictions on joints d) maximum allowable reinforcement e) inspection requirements

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III. NONDESTRUCTIVE EXAMINATION ASME Section V, Nondestructive Examination NOTE: The examination will cover only the main body of each referenced Article, except as noted: F. API-650 and API-653: General nondestructive examination requirements: 1. API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for NDE in API650, Section 8.

2. API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction: The inspector should be familiar with and understand the general rules for NDE in API-653, Section 12

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IV. PRACTICAL KNOWLEDGE - GENERAL B. Typical code requirements that candidates will NOT be expected to know for purposes of this certification examination.

1. Required thickness calculations for wind, earthquake, and small internal pressures 2. Nozzle calculations for external loads; 3. Flange calculations; 4. Brazing requirements; 5. Calculating venting requirements (API 650 5.8.5); 6. Ladder, stairway, and other structural type calculations; 7. NDE requirements for eddy current, and motion radiography per ASME Section V, Article 9 8. Technical interpretations of API & ASME Codes and Standards 9. Welding process requirements other than shielded metal arc welding (SMAW) and submerged arc welding (SAW)

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10. API 650, Annex D 11. API 650, Annex E 12. API 650, Annex F 13. API 650, Annex G Except for G1.

14. API 650 Annex I Except for 1.1 and 1.2 15. API 650, Annex J 16. API 650, Annex K 17. API 650, Annex L 18. API 650, Annex M Except for M1.

19. API 650 Annex O Except for O1 & O2 20. API 650, Annex P. 21. API 650, Annex R 22. API 650, Annex S Except for S1 23. API 650, Annex SC 24. API 650, Annex T. 25. API 650, Annex V. 26. API 650, Annex W. 27. API 650, Annex X 28. API 650, Annex Y Charlie Chong/ Fion Zhang

V. PRACTICAL KNOWLEDGE - SPECIFIC A. Each reference publication relative to study for the examination is listed below. A list of topics, which may be covered, is listed for each publication.

Some topics may be listed under more than one publication. For example; ASME Section IX is the basic document for welding requirements as referenced by API-650 and API-653. The referencing API documents contain additional welding requirements and exceptions or additions to those contained in ASME Section IX. Therefore, welding requirements may be listed under all three documents and all three documents may be listed under the general heading of “Welding on Tanks�.

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API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction and the related portions of API Standard 650, Welded Steel Tanks for Oil Storage (NOTE: all of API-653 is applicable to the examination unless specifically excluded.)

3. The inspector should have an understanding of the requirements for performing repairs and alterations such as: a) definitions of repairs and alterations b) repairs to foundations, shell plates, welds, tank bottoms, nozzles & penetrations, roofs, seals c) knowledge of the repair/alteration material and toughness requirements d) use of unidentified materials for repairs/alterations e) hot tap requirements and procedures f) inspection and NDE requirements for repairs and alterations g) hydrostatic and leak testing requirements h) lap welded patch plates (API-653, 9-3) i) new bottoms supported by grillage API-650, Annex I, excluding calculations)

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The Reading

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A. Calculation questions will be oriented toward existing tanks, not new tanks. API Authorized AST Inspectors should be able to check and perform calculations included in the following categories: 2. JOINT EFFICIENCIES The inspector must be able to determine the joint efficiency, "E", of a tank weld. Inspector should be able to determine: a) Joint Types (API-653 Section 4, Table 4-2) b) Type and extent of radiography performed (API 653, Table 4-2, Section 12; API 650, Section 8.1, Figure 8-1) c) Joint efficiency by reading API-653, Table 4-2 Determining joint efficiency may be part of a minimum thickness or maximum fill height problem since joint efficiency, "E", is used in the formulas for determining required thickness. (API-653, 4.3.3.1)

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SECTION 8—METHODS OF EXAMINING JOINTS NOTE In this standard, the term inspector, as used in Sections V and VIII of the ASME Code, shall be interpreted to mean the Purchaser’s inspector.

8.1 Radiographic Method For the purposes of this paragraph, plates shall be considered of the same thickness when the difference in their specified or design thickness does not exceed 3 mm (1/8 in.).

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8.1.1 Application Radiographic examination is required for shell butt-welds (see 8.1.2.2, 8.1.2.3, and 8.1.2.4), annular-plate butt-welds (see 8.1.2.9), and flush-type connections with butt-welds (see 5.7.8.11).

Radiographic examination is not required for the following: roof-plate welds, bottom-plate welds, welds joining the top angle to either the roof or shell, welds joining the shell plate to the bottom plate, welds in nozzle and manway necks made from plate, or appurtenance welds to the tank. (?)

Comments: RT mandatory on; ■ Annular plate butt-weld ■ Shell-to-shell butt-weld welds in nozzle and manway necks made from plate? 0RT? Insert plate’s welds?

100RT? (see 8.1.2.2 (d)) Charlie Chong/ Fion Zhang

8.1.2 Number and Location of Radiographs 8.1.2.1 Except when omitted under the provisions of A.3.4, radiographs shall be taken as specified in 8.1.2 through 8.1.9.

8.1.2.2 The following requirements apply to vertical joints. a) For butt-welded joints in which the thinner shell plate is less than or equal to 10 mm (3/8 in.) thick, one spot radiograph shall be taken in the first 3 m (10 ft) of completed vertical joint of each type and thickness welded by each welder or welding operator. The spot radiographs taken in the vertical joints of the lowest course may be used to meet the requirements of Note 3 in Figure 8.1 for individual joints. Thereafter, without regard to the number of welders or welding operators, one additional spot radiograph shall be taken in each additional 30 m (100 ft) (approximately) and any remaining major fraction of vertical joint of the same type and thickness. At least 25 % of the selected spots shall be at junctions of vertical and horizontal joints, with a minimum of two such intersections per tank. In addition to the foregoing requirements, one random spot radiograph shall be taken in each vertical joint in the lowest course (see the top panel of Figure 8.1).

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Figure 8.1—Radiographic Requirements for Tank Shells (1/4)

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Figure 8.1—Radiographic Requirements for Tank Shells (2/4) ≦10mm?

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Figure 8.1—Radiographic Requirements for Tank Shells (3/4)

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Figure 8.1—Radiographic Requirements for Tank Shells (4/4) Notes: 1. Vertical spot radiograph in accordance with 8.1.2.2, Item a: one in the first 3 m (10 ft) and one in each 30 m (100 ft) thereafter, 25 % of which shall be at intersections.

2. Horizontal spot radiograph in accordance with 8.1.2.3: one in the first 3 m (10 ft) and one in each 60 m (200 ft) thereafter.

3. Vertical spot radiograph in each vertical seam in the lowest course (see 8.1.2.2, Item b). Spot radiographs that satisfy the requirements of Note 1 for the lowest course may be used to satisfy this requirement.

4. Spot radiographs of all intersections over 10 mm (3/8 in.) (see 8.1.2.2, Item b).

5. Spot radiograph of bottom of each vertical seam in lowest shell course over 10 mm (3/8 in.) (see 8.1.2.2, Item b).

6. Complete radiograph of each vertical seam over 25 mm (1 in.). The complete radiograph may include the spot radiographs of the intersections if the film has a minimum width of 100 mm (4 in.) (see 8.1.2.2, Item c).

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6. Complete radiograph of each vertical seam over 25 mm (1 in.). The complete radiograph may include the spot radiographs of the intersections if the film has a minimum width of 100 mm (4 in.) (see 8.1.2.2, Item c). ≧4 in.

The complete radiograph may include the spot radiographs of the intersections (4)*

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Film (6)

b) For butt-welded joints in which the thinner shell plate is greater than 10 mm (3/8 in.) but less than or equal to 25 mm (1 in.) in thickness, spot radiographs shall be taken according to Item a. In addition, all junctions of vertical and horizontal joints in plates in this thickness range shall be radiographed; each film shall clearly show not less than 75 mm (3 in.) of vertical weld and 50 mm (2 in.) of weld length on each side of the vertical intersection. In the lowest course, two spot radiographs shall be taken in each vertical joint: one of the radiographs shall be as close to the bottom as is practicable, and the other shall be taken at random (see the center panel of Figure 8.1). c) Vertical joints in which the shell plates are greater than 25 mm (1 in.) thick shall be fully radiographed. All junctions of vertical and horizontal joints in this thickness range shall be radiographed; each film shall clearly show not less than 75 mm (3 in.) of vertical weld and 50 mm (2 in.) of weld length on each side of the vertical intersection (see the bottom panel of Figure 8.1).

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c) Vertical joints in which the shell plates are greater than 25 mm (1 in.) thick shall be fully radiographed. All junctions of vertical and horizontal joints in this thickness range shall be radiographed; each film shall clearly show not less than 75 mm (3 in.) of vertical weld and 50 mm (2 in.) of weld length on each side of the vertical intersection (see the bottom panel of Figure 8.1).

4 in.

3 in.

Film (4)

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d) The butt-weld around the periphery of an insert plate that extends less than the adjacent shell course height and that contains shell openings (i.e. nozzle, manway, flush-type cleanout, flush type shell-connection) and their reinforcing elements shall be completely radiographed. e) The butt-weld around the periphery of an insert plate which extends to match the adjacent shell course height shall have the vertical and the horizontal butt joints and the intersections of vertical and horizontal weld joints radiographed using the same rules that apply to the weld joints in adjacent shell plates in the same shell course.

e? d? d?

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8.1.2.3 One spot radiograph shall be taken in the first 3 m (10 ft) of completed horizontal butt joint of the same type and thickness (based on the thickness of the thinner plate at the joint) without regard to the number of welders or welding operators. Thereafter, one radiograph shall be taken in each additional 60 m (200 ft) (approximately) and any remaining major fraction of horizontal joint of the same type and thickness. These radiographs are in addition to the radiographs of junctions of vertical joints required by Item c of 8.1.2.2 (see Figure 8.1).

8.1.2.4 The number of spot radiographs required herein shall be applicable on a per tank basis, irrespective of the number of tanks being erected concurrently or continuously at any location.

8.1.2.5 It is recognized that in many cases the same welder or welding operator does not weld both sides of a butt joint. If two welders or welding operators weld opposite sides of a butt joint it is permissible to examine their work with one spot radiograph. If the radiograph is rejected, additional spot radiographs shall be taken (?) to determine whether one or both of the welders or welding operators are at fault.

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8.1.2.6 An equal number of spot radiographs shall be taken from the work of each welder or welding operator in proportion to the length of joints welded.

8.1.2.7 As welding progresses, radiographs shall be taken as soon as it is practicable. The locations where spot radiographs are to be taken may be determined by the Purchaser’s inspector.

8.1.2.8 Each radiograph shall clearly show a minimum of 150 mm (6 in.) of weld length. The film shall be centered on the weld and shall be of sufficient width to permit adequate space for the location of identification marks and an image quality indicator (IQI) penetrometer

minimum diagnostic length of 6 in.

Actual length shall ≧ 6 in. to include sufficient overlapped

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8.1.2.9 When bottom annular plates are required by 5.5.1, or by M.4.1, the radial joints shall be radiographed as follows: (a) For double-welded butt joints, one spot radiograph shall be taken on 10 % of the radial joints; (?) (b) For single-welded butt joints with permanent or removable back-up bar, one spot radiograph shall be taken on 50 % of the radial joints. (?)

Extra care must be exercised in the interpretation of radiographs of singlewelded joints that have a permanent back-up bar. In some cases, additional exposures taken at an angle may determine whether questionable indications are acceptable. The minimum radiographic length of each radial joint shall be 150 mm (6 in.). Locations of radiographs shall preferably be at the outer edge of the joint where the shell plate and annular plate join.

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8.1.3 Technique 8.1.3.1 Except as modified in this section, the radiographic examination method employed shall be in accordance with Section V, Article 2, of the ASME Code.

8.1.3.2 Personnel who perform and evaluate radiographic examinations according to this section shall be qualified and certified by the Manufacturer as meeting the requirements of certification as generally outlined in Level II or Level III of ASNT SNT-TC-1A (including applicable supplements). Level-I personnel may be used if they are given written acceptance/rejection procedures prepared by Level-II or Level-III personnel. These written procedures shall contain the applicable requirements of Section V, Article 2, of the ASME Code. In addition, all Level-I personnel shall be under the direct supervision of Level-II or Level-III personnel.

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8.1.3.3 The requirements of T-285 in Section V, Article 2, of the ASME Code are to be used only as a guide. Final acceptance of radiographs shall be based on whether the prescribed penetrameter image and the specified hole can be seen.

8.1.3.4 The finished surface of the weld reinforcement at the location of the radiograph shall either be flush with the plate or have a reasonably uniform crown not to exceed the following values:

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8.1.4 Submission of Radiographs Before any welds are repaired, the radiographs shall be submitted to the inspector with any information requested by the inspector regarding the radiographic technique used.

8.1.5 Radiographic Standards Welds examined by radiography shall be judged as acceptable or unacceptable by the standards of Paragraph UW-51(b) in Section VIII of the ASME Code.

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8.1.6 Determination of Limits of Defective Welding When a section of weld is shown by a radiograph to be unacceptable under the provisions of 8.1.5 or the limits of the deficient welding are not defined by the radiograph, two spots adjacent to the section shall be examined by radiography; however, if the original radiograph shows at least 75 mm (3 in.) of acceptable weld between the defect and any one edge of the film, an additional radiograph need not be taken of the weld on that side of the defect.

If the weld at either of the adjacent sections fails to comply with the requirements of 8.1.5, additional spots shall be examined until the limits of unacceptable welding are determined, or the erector may replace all of the welding performed by the welder or welding operator on that joint. If the welding is replaced, the inspector shall have the option of requiring that one radiograph be taken at any selected location on any other joint on which the same welder or welding operator has welded. If any of these additional spots fail to comply with the requirements of 8.1.5, the limits of unacceptable welding shall be determined as specified for the initial section.

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if the original radiograph shows at least 75 mm (3 in.) of acceptable weld between the defect and any one edge of the film, an additional radiograph need not be taken of the weld on that side of the defect.

3 in.?

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http://www.sentinelltd.co.nz/Sentinel

8.1.7 Repair of Defective Welds 8.1.7.1 Defects in welds shall be repaired by chipping or melting out the defects from one side or both sides of the joint, as required, and rewelding.

Only the cutting out of defective joints that is necessary to correct the defects is required.

8.1.7.2 All repaired welds in joints shall be checked by repeating the original examination procedure and by repeating one of the testing methods of 7.3, subject to the approval of the Purchaser.

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8.1.8 Record of Radiographic Examination 8.1.8.1 The Manufacturer shall prepare a radiograph map showing the final location of all radiographs taken along with the film identification marks.

8.1.8.2 After the structure is completed, the films shall be the property of the Purchaser unless otherwise agreed upon by the Purchaser and the Manufacturer.

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4. WELD SIZES FOR SHELL & ROOF OPENINGS The inspector should be familiar with determining the sizes and spacing of welds for shell openings to the extent of being able to use the information in the following Figures and Tables: a) API-650, Figures 5-7a, 5-7b, 5-8, 5-9, 5-12, 5-14, 5-16, 5-17, 5-19, 5-20, 521 b) API-650, Tables 5-6, 5-7, 5-9 c) API-653, Figures 9-1, 9-2, 9-4, 9-5

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500 mm (20 in.) and 600 mm (24 in.) shell manholes: twenty-eight 20 mm-diameter (3/4 in.) bolts in 23 mm (7/8 in.) holes 750 mm (30 in.) and 900 mm (36 in.) shell manholes: forty-two 20 mm-diameter (3/4 in.) bolts in 23 mm (7/8 in.) holes (Bolt holes shall straddle the flange vertical centerline.)

Gasket (see Note 1):

(See Figure 5-7b)

500 mm (20 600 mm (24 750 mm (30 900 mm (36

in.) manhole: 645 mm (253/8 in.) manhole: 746 mm (293/8 in.) manhole: 899 mm (353/8 in.) manhole: 1051 mm (413/8

in.) OD c 508 mm (20 in.) OD c 610 mm (24 in.) OD c 762 mm (30 in.) OD c 914 mm (36

in.) ID c 3 mm (1/8 in.) thickness in.) ID c 3 mm (1/8 in.) thickness in.) ID c 3 mm (1/8 in.) thickness in.) ID c 3 mm (1/8 in.) thickness

One 6 mm (1/4 in.) telltale hole in reinforcing plate, on horizontal centerline

Reinforcing pad shall be shaped to suit tank curvature

tf

1 1

tc 230 mm (9 in.)

CL

L (see Note 8)

DR/2 (see Note 8)

DO/2 (see Note 8)

L

6 mm (1/4 in.)

10 mm-diameter (3/8 in.) rod

Db

Dc

DR

CL

See Figure 5-7b

T t

500 mm (20 in.) and 600 mm (24 in.) manhole: 750 mm (30 in.)

750 mm (30 in.) manhole: 900 mm (36 in.)

900 mm (36 in.) manhole: 1050 mm (42 in.)

(Increase as necessary for weld clearance) Rounded corners

Manhole OD

DP

See details

6 mm ( / in.)

125 mm (5") minimum 32 mm (11/4 in.)

Rounded corners (150 mm [6 in.] minimum radius)

OD

150 mm (6 in.)

1 4

Arc dimension = W/2

Uniform, smooth surface Rounded corner

tn

75 mm (3")

Symmetrical about CL

Alternative circular shape (see Note 8)

(See Note 7)

Manhole OD

tn (see Note 4)

tn (see Note 4) See Note 5

See Note 2

t f (see Note 3)

See Note 2

Detail a

t f (see Note 3)

Detail b

NOTES 1. Gasket material shall be specified by the Purchaser. See 5.7.5.4.

2. The gasketed face shall be machine-finished to provide a minimum gasket-bearing width of 19 mm (3/4 in.).

3. See Table 5.3a and Table 5.3b.

4. See Table 5.4a and Table 5.4b.

5. The size of the weld shall equal the thickness of the thinner member joined.

6. The shell nozzles shown in Figure 5.8 may be substituted for manholes.

minimum centerline elevations allowed by Table 5.6a, Table • 7. The 5.6b, and Figure 5.6 may be used when approved by the Purchaser.

8. For dimensions for OD, DR, Do, L, and W, see Table 5.6a and Table 5.6b, Columns 2, 4, 5, and 6. For Dimension DP see Table 5.7a and Table 5.7b, Column 3.

9. At the option of the Manufacturer, the manhole ID may be set to the OD dimension listed in Table 5.6a and Table 5.6b, Column 2.

Reinforcement area and weld spacing must meet 5.7.2 and 5.7.3 requirements respectively.

Figure 5.7a—Shell Manhole

(See Tables 5-7a and 5-7b) A

J

J

1.5 mm (1/16 in.)

tn A

Round corner if weld <T

(See Tables 5-7a and 5-7b)

(See Tables 5-7a and 5-7b)

A [10 mm (3/8 in.) maximum]

Round corner if weld <T T or t [40 mm (11/2 in.) maximum] T

T or t [40 mm (11/2 in.) maximum]

t

T

Manhole or Nozzle

Nozzle CL

CL

t (min)

J

+T) min

DO (min)

45º

45º 1.5 mm (1/16 in.)

T+t A (min) [10 mm (3/8 in.) maximum]

(See Tables 5-7a and 5-7b)

Alternative bevel T+t (min)

t

1:4 bevel

(See Note 2)

(See Note 2)

Radiograph (see 8.1.2.2, Item d)

t

(See Note 2)

1:4 bevel

45º (See Tables 5-7a and 5-7b) 1 16 1.5 mm (1/16 in.)

1.5 mm ( / in.)

A A 3/ in.) maximum] T+t [10 mm ( 8 (See Note 3) (min) 1:4 bevel Alternative Radiograph neck detail (see 8.1.2.2, t Item d)

DO (min)

tn

Shell joint or outer periphery of insert plate

J 1/3 (t

L and W or DO

Round and grind corner

+ t) min

(see Tables 5-6a and 5-6b)

1/3 (T

t Nozzle

Neck bevel should be about 10 degrees

(See Tables 5-6a, 5-6b, 5-7a, and 5-7b)

Manufacturer’s standard (15 degrees minimum, 35 degrees maximum)

tn

CL

(See Note 1)

(See Note 1)

1.5 mm (1/16 in.)

(See Tables 5-6a, 5-6b, 5-7a, and 5-7b)

Round and grind (See Tables 5-6a, 5-6b, 5-7a, and 5-7b)

Manufacturer’s standard (15 degrees minimum, 35 degrees maximum)

Neck bevel should be about 10 degrees

L and W (Tables 5-6a and 5-6b) or DO

Nozzle CL

Radiograph (see 8.1.2.2, Item d and e)

Shell Bottom Insert-type Reinforcement for Manholes and Nozzles

Notes: 1. See Table 5.7a and Table 5.7b, Column 3, for the shell cutout, which shall not be less than the outside diameter of the neck plus 13 mm (1/2) in.

2. See 5.7.3 for minimum spacing of welds at opening connections.

3. The weld size shall be either A (from Table 5.7a and Table 5.7b, based on t) or tn (minimum neck thickness from Table 5.4a, Table 5.4b, Table 5.6a, Table 5.6b, Table 5.7a and Table 5.7b), whichever is greater.

•

4. Other permissible insert details are shown in Figure 5.8 of API Standard 620.

The reinforcement area shall conform to 5.7.2.

5. Dimensions and weld sizes that are not shown are the same as those given in Figure 5.7a and Table 5.4a through Table 5.8b.

6. Details of welding bevels may vary from those shown if agreed to by the Purchaser.

Figure 5.7b—Details of Shell Manholes and Nozzles

W DP

1

One 6 mm (1/4 in.) telltale hole in reinforcing plate, on horizontal centerline

L

1 DR/2

DO

Arc distance

DR

DP DR

Bend reinforcing plate to radius of tank shell

L

Alternative shape for low-type nozzles DR/2

See Detail A or B for bottom edge Diamond

J

J t

t

J Q

Circular

Reinforcing Plate

Q

T

T

J Q

Q

T

OD

OD

OD (See Figure 5-7b)

J t

(See Figure 5-7b)

(See Figure 5-7b)

HN

Victaulic groove or threads Tank bottom B

B

B Double Flange

Single Flange

Special Flange

Regular-type Flanged Nozzles, NPS 3 or Larger (Bolt holes shall straddle flange centerlines) Nozzle CL (See Figure 5-7b)

(See Note 1)

C T

Chip (See Note 1)

T t

(See Note 1)

t

60º

t /2 [6 mm (1/4 in.) minimum] (See Note 5)

Detail A Detail B Low-type Flanged Nozzles, NPS 3 or Larger (Bolt holes shall straddle flange centerlines) NOTES 1. See 5.1.5.7 for information on the size of welds.

2. See 5.8.9 for information on the couplings used in shell nozzles.

3. Nozzles NPS 3 or larger require reinforcement.

•

4. Details of welding bevels may vary from those shown if agreed to by the Purchaser.

5. Shop weld not attached to bottom plate.

6. See 5.7.6.2 for information on supplying nozzles flush or with an internal projection.

Figure 5.8—Shell Nozzles (see Tables 5.6a, 5.6b, 5.7a, 5.7b, 5.8a, and 5.8b)

t

Low type

Regular

t

Dimension A = size of fillet weld A (see Note 1)

J A (see Note 7)

0

t

10 mm (3/8 in.) maximum

A

11/4 tmin (see Note 8)

CL

t

10 mm (3/8 in.) maximum 11/4 tmin (see Note 8)

45Âş HN

C

Shell

Bottom

Shell 1.5 mm (1/16 in.)

A (see Note 7) Bottom

Type A

Shell

Bottom Type B

Shell

Bottom Type C

Couplings and Flanged Fittings, NPS 3/4 Through NPS 2 (see Note 3) NOTES (continued) 7. See Table 5.7a and Table 5. 7b, Column 6.

8. tmin shall be 19 mm (3/4 in.) or the thickness of either part joined by the fillet weld, whichever is less.

9. The construction details apply to unreinforced threaded, non-threaded, and flanged nozzles.

Figure 5.8â&#x20AC;&#x201D;Shell Nozzles (continued)

Type D

14

Minimum spacing shall be 8 times the shell thickness or 1/2 the radius of the opening, whichever is less

See 5.7.3

1.5DP 1.5DP

Extent of radiography

CL of butt-welded shell joint

Toe of weld Detail a

Detail b

Penetration Without Reinforcing Plate

Minimum spacing shall be 8 times the shell thickness See 5.7.3

CL of butt-welded shell joint

Minimum spacing shall be 8 times the shell thickness or 1/2 the radius of the opening, whichever is less

1.5DP

Toe of weld

Toe of weld

Reinforcing plate Detail c

Note: Dp = diameter of opening.

Reinforcing plate Detail d

Detail e

Penetration With Reinforcing Plate

Figure 5.9â&#x20AC;&#x201D;Minimum Spacing of Welds and Extent of Related Radiographic Examination

Extent of radiography

1.5DP

Extent of radiography 1.5DP 1.5DP

CL of butt-welded shell joint

A td

Nearest horizontal weld 375 mm (15 in.) min

Shell plate at cleanout fitting = td

See Detail a

(See Note 5)

125 mm (5 in.)

Reinforcing plate = td

See Detail b

Shell plate of lowest shell course = t

See Detail b for top and sides

(See Note 5)

One telltale 6 mm (1/4 in.) hole in reinforcing plate at about mid-height

r2 r1

L tc

C

e

6 mm (1/4 in.)

(See Note 1)

f3

Equal spaces g

B

Flange bolt-hole diameter = bolt diameter (see Tables 5-9a and 5-9b) + 3 mm (1/8 in.)

h

C

b/2

6 mm (1/4 in.)

Bottom plate

f2

B f3 ﾃｭ 6 mm (1/4 in.)

Equal spaces

150 mm 300 mm W/2 arc dimensions (6 in.) min (12 in.) min Notch as required to provide flush joint under shell ring (see Section D-D) td

td

175 mm (5 in.)

50 mm (2 in.)

Full-fillet weld

(See Note 1)

38 mm (11/2")

e

6 mm (1/4 in.)

A

Section A-A 10 mm (3/8 in.) thick Grind radius on corner when weld is less than td 38 mm (11/2")

5 mm (3/16 in.)

75 mm (3 in.)

or

1

6 mm ( /4")

td [40 mm (11/2 in.) max]

Lifting Lug

38 mm (11/2")

tb

td

5 mm (3/16 in.)

Section B-B

Cover plate Detail a

75 mm (3 in.) radius 90 degrees ﾂｱ 30 degrees

tc

D

e

125 mm (5 in.) min

Full-penetration weld

(See Note 3)

(See Note 1)

6 mm (1/4 in.)

Section D-D 6 mm (1/4 in.)

32 mm (11/4 in.) min

6 mm (1/4 in.)

5 mm (3/16 in.)

f3

32 mm (11/4 in.) min 32 mm (11/4 in.) min

td

Detail b

Versine

D

tb

td + td + 250 mm (10 in.) t (see Note 2) [19 mm (3/4 in.) max]d

Round and grind

td (See Note 5) Neck bevel shall be approximately 10 degrees

Section C-C

Notes: 1. Thickness of thinner plate joined (13 mm [1/2 in.] maximum).

2. When an annular plate is provided, the reinforcing plate shall be regarded as a segment of the annular plate and shall be the same width as the annular plate.

3. When the difference between the thickness of the annular ring and that of the bottom reinforcing plate is less than 6 mm (1/4 in.), the radial joint between the annular ring and the bottom reinforcing plate

窶｢

may be butt-welded with a weld joint suitable for complete penetration and fusion.

4. Gasket material shall be specified by the Purchaser. The gasket material shall meet service requirements based on product stored, design metal temperature, maximum design temperature and fire resistance.

5. The thickness (td) of the shell plate at the cleanout opening, the reinforcing plate, and the neck plate, shall be equal to or greater than the thickness (t) of the shell plate of the lowest shell course.

Figure 5.12窶認lush-Type Cleanout Fittings (see Tables 5.9a, 5.9b, 5.10a, 5.10b, 5.11a, and 5.11b)

C

Centerline of connection

Shell or insert plate in flush connection = td

Shell plate of lowest shell course = t

375 mm (15 in.) min

Reinforcing plate = td

See Section C-C (Figure 5-11 â&#x20AC;&#x201D; continued)

150 mm (6 in.) min

r2 L r1 One 6 mm (1/4") telltale hole in reinforcing plate at about mid-height B

h B

tn = 16 mm (5/8 in.) min b/2

W/2 arc dimensions

Full-penetration weld

150 mm 300 mm (6 in.) min (12 in.) min Bottom reinforcing plate Notch as required to provide flush joint

75 mm (3 in.)

C

32 mm (11/4 in.) min

32 m

m(

1 1/4

in.)

Bottom plate

All joints approximately 90 degrees

min

600 m (24 i m n.) m in

Full-fillet weld

50 m

Bottom transition plate for minimum arc dimension of W + 1500 mm (60 in.) m (2

in.) m

in

75 mm (3 in.) radius A

125 mm (5 in.) min 2td + 250 mm (10 in.)

A Bottom reinforcing plate

Section B-B

td

Butt-weld Nozzle transition to circular flange

td 5 mm (3/16 in.)

6 mm (1/4 in.)

(See Note 2)

Butt-weld

Centerline of connection

Figure 5.14â&#x20AC;&#x201D;Flush-type Shell Connection

tb Section A-A

16-mm (5/8-in.) diameter bolts in 20-mm (3/4 in.) diameter holes (see Table 5-13a and Table 5-13b for number of bolts; bolt holes shall straddle centerlines)

A

A

150 mm (6 in.)

6 mm (1/4 in.) cover plate 150 mm (6 in.)

6 mm (1/4 in.) cover plate

6 mm (1/4 in.)

DC DB

75 mm (3 in.)

1.5 mm (1/16 in.) thick gasket

6 mm

6 mm (1/4 in.)

5 mm (3/16 in.)

Alternative Flange Detail

150 mm (6 in.)

6 mm (1/4 in.)

Reinforcing plate (1/4

6 mm (1/4 in.)

16 mm (5/8 in.) diameter rod

Axis always vertical

in.)

150 mm (6 in.) min

or 6 mm

(1/4 in.)

5 mm (3/16 in.)

ID

Roof plate

DP DR Section A-Aâ&#x20AC;&#x201D;Roof Manhole With Reinforcing Plate

Alternative Neck-toRoof-Plate Joint 6 mm (1/4 in.)

6 mm (1/4 in.)

ID

Roof plate

DP Base For Roof Manhole Without Reinforcing Plate

Figure 5.16â&#x20AC;&#x201D;Roof Manholes (see Table 5.13a and Table 5.13b)

Grind flush Typical 45º Section A-A, Typical

75 mm (3 in.) typical

A A 125 mm (5 in.) typical

Typical

Neck 6 mm (1/4 in.) thick min.

B

1800 mm (6 ft) max

B Except for handles, cover plate not shown.

16 mm (5/8 in.) diameter rod, 4 places

900 mm (3 ft) max 1.5 mm (1/16 in.) thick gasket 150 mm (6 in.)

5 mm (3/16 in.) galv. wirerope lanyard

Cover 5 mm (3/16 in.) thick minimum

5 mm (3/16 in.) typical

100 mm (4 in.) minimum 75 mm (3 in.) x 10 mm (3/8 in.) bar flange

75 mm (3 in.)

250 mm (10 in.) max

Note 3 Note 1 Roof plate 38 mm (1.5 in.) x 38 mm (1.5 in.) x 6 mm (1/4 in.) tab Section B-B 1

6 mm ( /4 in.) reinforcing plate, when required. See Note 4.

•

Notes: 1. Weld size shall be the smaller of the plate thicknesses being joined.

2. Cover may be either parallel to roof or horizontal. Opening may be oriented as desired.

3. Bolts shall be 16-mm (5/8-in.) diameter in 20-mm (3/4-in.) holes, which shall be equally spaced and shall not exceed 125-mm (5 in.) on center.

4. When required, provide 6-mm (1/4-in.) reinforcing plate. Width at least 1/2 smallest opening dimension. Round outside corners with 75 mm (3 in.) radius, minimum. Seams shall be square groove butt-welded.

Figure 5.17—Rectangular Roof Openings with Flanged Covers

Axis always vertical

Axis always vertical Plain or raised-face slip-on welding, welding-neck, or plate ring flange 5 mm (3/16 in.)

HR

6 mm (1/4 in.)

Alternative Neck-to-Roof-Plate Joint 6 mm (1/4 in.)

(See note) 6 mm (1/4 in.)

DR

Roof plate

Roof plate DP

Standard-weight line pipe

DP Nozzle with Reinforcing Plate

Base for Nozzle without Reinforcing Plate

Note: When the roof nozzle is used for venting, the neck shall be trimmed flush with the roofline.

Figure 5.19—Flanged Roof Nozzles (see Table 5.14a and Table 5.14b) Axis always vertical

Axis always vertical (See note)

6 mm (1/4 in.)

6 mm (1/4 in.)

6 mm (1/4 in.)

5 mm (3/16 in.)

Roof plate DP

Roof plate

Pipe coupling

DR

DP Nozzle without Reinforcing Plate

Nozzle with Reinforcing Plate

Note: See 5.8.9 for requirements for threaded connections. When the roof nozzle is used for venting, the neck shall be trimmed flush with the roofline.

Figure 5.20—Threaded Roof Nozzles (see Table 5.15a and Table 5.15b) C Tank shell

8 mm (5/16 in.)

Full fillet Detail a2

Detail a1 6 mm (1/4 in.)

6 mm (1/4 in.)

Internal pipe Nozzle neck

60

Detail a3

Full fillet weld

Tack-weld backup bar to flange

t Tank bottom B

t

1 pipe diameter (min)

100 mm (4 in.)

Sand cushion

t A

Detail a4

Full fillet 8 mm (5/16 in.)

6HH 'HWDLOV D íD 6 mm (1/4 in.)

6 mm (1/4 in.)

6 mm (1/4 in.)

6 mm (1/4 in.)

See Detail b, c, or d

Detail b

Full fillet 8 mm (5/16 in.)

Detail c

Detail d

NOTE The erection procedure shall be performed by one of the following methods or by an alternate design approved by a Storage Tank Engineer: a) For sumps being placed in the foundation before bottom placement, the sump shall be placed in position with at least 100 mm (4 in.) of thoroughly compacted sand, or other suitable fill material, around the sump. The sump then shall be welded to the bottom. b) For sumps being placed in the foundation after bottom placement, sufficient bottom plate shall be removed to allow for the sump to be placed in position with at least 100 mm (4 in.) of thoroughly compacted sand, or other suitable fill material, around the sump. The sump shall then be welded to the bottom.

Figure 5.21—Drawoff Sump (see Table 5.16a and Table 5.16b)

Table 5.6aâ&#x20AC;&#x201D;Dimensions for Shell Nozzles (SI) Dimensions in millimeters Column 1 NPS (Size of Nozzle)

Column 2

Column 3

Nominal Thickness Outside Diameter of of Flanged Nozzle Pipe Pipe Walla OD tn

Column 4

Column 5

Column 6

Length of Diameter of Side of Width of Hole in Reinforcing Reinforcing Reinforcing Plateb or Plate Plate W Diameter DR L = Do

Column 7 Minimum Distance from Shellto-Flange Face J

Column 8

Column 9c

Minimum Distance from Bottom of Tank to Center of Nozzle Regular Typed HN

Low Type C

Flanged Fittings 1524.0

e

1528

3068

3703

400

1641

1534

1371.6

e

1375

2763

3341

400

1488

1382

1320.8

e

1324

2661

3214

400

1437

1331

50

1270.0

e

1274

2560

3093

400

1387

1280

48

1219.2

e

1222

2455

2970

400

1334

1230

46

1168.4

e

1172

2355

2845

400

1284

1180

1117.6

e

1121

2255

2725

375

1234

1125

42

1066.8

e

1070

2155

2605

375

1184

1075

40

1016.0

e

1019

2050

2485

375

1131

1025

965.2

e

968

1950

2355

350

1081

975

914.4

e

918

1850

2235

350

1031

925

34

863.6

e

867

1745

2115

325

979

875

32

812.8

e

816

1645

1995

325

929

820

762.0

e

765

1545

1865

300

879

770

60 54 52

44

38 36

30

Table 5.6a—Dimensions for Shell Nozzles (SI) (Continued) Dimensions in millimeters Column 1 NPS (Size of Nozzle)

Column 2

Column 3

Nominal Thickness Outside Diameter of of Flanged Nozzle Pipe Pipe Walla OD tn

Column 4

Column 5

Column 6

Length of Diameter of Side of Width of Hole in Reinforcing Reinforcing Reinforcing Plateb or Plate Plate Diameter W DR L = Do

Column 7 Minimum Distance from Shellto-Flange Face J

Column 8

Column 9c

Minimum Distance from Bottom of Tank to Center of Nozzle Regular Typed HN

Low Type C

28

711.2

e

714

1440

1745

300

826

720

26

660.4

e

664

1340

1625

300

776

670

24

609.6

12.7

613

1255

1525

300

734

630

22

558.8

12.7

562

1155

1405

275

684

580

20

508.0

12.7

511

1055

1285

275

634

525

18

457.2

12.7

460

950

1160

250

581

475

16

406.4

12.7

410

850

1035

250

531

425

14

355.6

12.7

359

750

915

250

481

375

12

323.8

12.7

327

685

840

225

449

345

10

273.0

12.7

276

585

720

225

399

290

8

219.1

12.7

222

485

590

200

349

240

6

168.3

10.97

171

400

495

200

306

200

4

114.3

8.56

117

305

385

175

259

150

3

88.9

7.62

92

265

345

175

239

135

2f

60.3

5.54

63

—

—

150

175

h

11/2f

48.3

5.08

51

—

—

150

150

h

1f

33.4

6.35

—

—

—

150

150

h

3/4f

26.7

5.54

—

—

—

150

150

h

Threaded and Socket-Welded Couplings

●

3g

108.0

Coupling

111.1

285

360

—

245

145

2f

76.2

Coupling

79.4

—

—

—

175

h

11/2f

63.5

Coupling

66.7

—

—

—

150

h

1f

44.5

Coupling

47.6

—

—

—

150

h

3/4f

35.0

Coupling

38.1

—

—

—

150

h

a

For extra-strong pipe, see ASTM A53M or A106M for other wall thicknesses; however, piping material must conform to 4.5.

b

The width of the shell plate shall be sufficient to contain the reinforcing plate and to provide clearance from the girth joint of the shell course.

c

Low type reinforced nozzles shall not be located lower than the minimum distance shown in Column 9. The minimum distance from the bottom shown in Column 9 complies with spacing rules of 5.7.3 and Figure 5.6.

d

Regular type reinforced nozzles shall not be located lower than the minimum distance HN shown in Column 8 when shell thickness is equal to or less than 12.5 mm. Greater distances may be required for shells thicker than 12.5 mm to meet the minimum weld spacing of 5.7.3 and Figure 5.6.

e

See Table 5.7a, Column 2.

f

Flanged nozzles and couplings in pipe sizes NPS 2 or smaller do not require reinforcing plates. DR will be the diameter of the hole in the shell plate, and Weld A will be as specified in Table 5.7a, Column 6. Reinforcing plates may be used if the construction details comply with reinforced nozzle details.

g

A coupling in an NPS 3 requires reinforcement.

h

See 5.7.3 and Figure 5.6.

NOTE

See Figure 5.8.

Table 5.7aâ&#x20AC;&#x201D;Dimensions for Shell Nozzles: Pipe, Plate, and Welding Schedules (SI) Dimensions in millimeters Column 1

Column 2

Column 3

Column 4

Thickness of Shell and Reinforcing Platea t and T

Minimum Pipe Wall Thickness of Flanged Nozzlesb tn

Maximum Diameter of Hole in Shell Plate (Dp) Equals Outside Diameter of Pipe Plus

Size of Fillet Weld B

5

12.7

16

6

12.7

8

Column 5

Column 6

Size of Fillet Weld A Nozzles Larger Than NPS 2

NPS 3/4 to 2 Nozzles

5

6

6

16

6

6

6

12.7

16

8

6

6

10

12.7

16

10

6

6

11

12.7

16

11

6

6

13

12.7

16

13

6

8

14

12.7

20

14

6

8

Table 5.7aâ&#x20AC;&#x201D;Dimensions for Shell Nozzles: Pipe, Plate, and Welding Schedules (SI) (Continued) Dimensions in millimeters Column 1

Column 2

Column 3

Column 4

Thickness of Shell and Reinforcing Platea t and T

Minimum Pipe Wall Thickness of Flanged Nozzlesb tn

Maximum Diameter of Hole in Shell Plate (Dp) Equals Outside Diameter of Pipe Plus

Size of Fillet Weld B

16

12.7

20

17

12.7

20

Column 5

Column 6

Size of Fillet Weld A Nozzles Larger Than NPS 2

NPS 3/4 to 2 Nozzles

16

8

8

20

18

8

8

12.7

20

20

8

8

21

12.7

20

21

10

8

22

12.7

20

22

10

8

24

12.7

20

24

10

8

25

12.7

20

25

11

8

27

14

20

27

11

8

28

14

20

28

11

8

30

16

20

30

13

8

32

16

20

32

13

8

33

18

20

33

13

8

35

18

20

35

14

8

36

20

20

36

14

8

38

20

20

38

14

8

40

21

20

40

14

8

41

21

20

40

16

8

43

22

20

40

16

8

45

22

20

40

16

8

a

If a shell plate thicker than required is used for the product and hydrostatic loading (see 5.6), the excess shell-plate thickness, within a vertical distance both above and below the centerline of the hole in the tank shell plate equal to the vertical dimension of the hole in the tank shell plate, may be considered as reinforcement, and the thickness T of the nozzle reinforcing plate may be decreased accordingly. In such cases, the reinforcement and the attachment welding shall conform to the design limits for reinforcement of shell openings specified in 5.7.2.

b

This column applies to flanged nozzles NPS 26 and larger. See 4.5 for piping materials.

NOTE

See Figure 5.8.

b) The portion lying within the shell-plate thickness. c) The portion extending inward from the inside surface of the tank shell plate to the distance specified in Item a.

Table 5.9a—Dimensions for Flush-Type Cleanout Fittings (SI) Dimensions in millimeters Column 1

●

Column 2

Column 3

Column 4

Column 5

Column 6

Column 7

Column 8

Column 9

Column Column 10 11

Upper Upper Arc Width Corner Corner Edge Height of Width of of Shell Radius of Distance Radius Opening Opening Reinforcing Shell of Bolts of h b Reinforcing Plate e Opening Plate W r1 r2

Flange Widtha (Except at Bottom) f3

Bottom Flange Width f2

Special Number Diameter Bolt of of b Spacing Bolts Bolts g

203

406

1170

100

360

32

102

89

83

22

20

610

610

1830

300

740

38

102

95

89

36

20

914

1219

2700

610

1040

38

114

121

108

46

24

1219c

1219

3200

610

1310

38

114

127

114

52

24

a

For neck thicknesses greater than 40 mm, increase f3 as necessary to provide a 1.5 mm clearance between the required neck-to-flange weld and the head of the bolt.

b

Refers to spacing at the lower corners of the cleanout-fitting flange.

c

Only for Group I, II, III, or IIIA shell materials (see 5.7.7.2).

NOTE

See Figure 5.12.

Table 5.9b—Dimensions for Flush-Type Cleanout Fittings (USC) Dimensions in inches Column 1

●

Column 2

Column 3

Column 4

Column 5

Column 6

Column 7

Column 8

Column 9

Column 10

Column 11

Upper Upper Arc Width Corner Height Corner Edge Width of of Shell Radius of of Radius Distance Opening Reinforcing Shell Opening of of Bolts b Reinforcing Plate Opening e h Plate W r1 r2

Flange Widtha (Except at Bottom) f3

Bottom Flange Width f2

Special Number Diameter Bolt of of Spacingb Bolts Bolts g

8

16

46

4

14

11/4

4

31/2

31/4

22

3/4

24

24

72

12

29

11/2

4

33/4

31/2

36

3/4

36

48

106

24

41

11/2

41/2

43/4

41/4

46

1

48c

48

125

24

511/2

11/2

41/2

5

41/2

52

1

a

For neck thicknesses greater than 19/16 in., increase f3 as necessary to provide a 1/16 in. clearance between the required neck-to-flange weld and the head of the bolt.

b

Refers to spacing at the lower corners of the cleanout-fitting flange.

c

Only for Group I, II, III, or IIIA shell materials (see 5.7.7.2).

NOTE

See Figure 5.12.

8. IMPACT TESTING The inspector should understand the importance of tank materials having adequate toughness. The inspector should be able to determine: a) Tank design metal temperature (API-650, 4.2.9.3 & Figure 4-2) b) Material Group Number for a plate (API-650, Tables 4-3a and 4-3b) c) If impact testing is required (API-650, Figure 4-1a and 4-1b) d) If impact test values are acceptable (API-650, Table 4-4a and 4-4b)

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4.2.9 Impact Testing of Plates 4.2.9.1 When required by the Purchaser or by 4.2.10, a set of Charpy V-notch impact specimens shall be taken from plates after heat treatment (if the plates have been heat treated), and the specimens shall fulfill the stated energy requirements. Test coupons shall be obtained adjacent to a tension-test coupon. Each full-size impact specimen shall have its central axis as close to the plane of one-quarter plate thickness as the plate thickness will permit.

4.2.9.2 When it is necessary to prepare test specimens from separate coupons or when plates are furnished by the plate producer in a hot-rolled condition with subsequent heat treatment by the fabricator, the procedure shall conform to ASTM A20.

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4.2.9.3 An impact test shall be performed on three specimens taken from a single test coupon or test location. The average value of the specimens (with no more than one specimen value being less than the specified minimum value) shall comply with the specified minimum value. If more than one value is less than the specified minimum value, or if one value is less than twothirds the specified minimum value, three additional specimens shall be tested, and each of these must have a value greater than or equal to the specified minimum value.

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Figure 4.1aâ&#x20AC;&#x201D;Minimum Permissible Design Metal Temperature for Materials Used in Tank Shells without Impact Testing (SI)

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NOTE 1 The Group II and Group V lines coincide at thicknesses less than 13 mm.

NOTE 2 The Group III and Group IIIA lines coincide at thicknesses less than 13 mm.

NOTE 3 The materials in each group are listed in Table 4.4a and Table 4.4b.

NOTE 4 Deleted.

NOTE 5 Use the Group IIA and Group VIA curves for pipe and flanges (see 4.5.4.2 and 4.5.4.3).

NOTE 6 Linear equations provided in Table 4.3a can be used to calculate Design Metal Temperature (DMT) for each API material group and the thickness range.

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Figure 4.2—Isothermal Lines of Lowest One-Day Mean Temperatures (°F)

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Table 4.3aâ&#x20AC;&#x201D;Linear Equations for Figure 4.1a (SI)

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10. RECONSTRUCTED TANK SHELL - MINIMUM THICKNESS The inspector should be able to determine the minimum thickness of the shell of a reconstructed tank. The inspector should be able to: a) Determine “Sd”, allowable stress for design condition (API-650, table 5-2, API-653, 8.4.2) b) Determine “St”, allowable stress for hydrostatic test condition (API-650, Table 5-2, API-653, 8.4.3) c) Calculate “td”, design shell thickness (API-650, 5.6.3.2, for tanks of 200 foot diameter and smaller) d) Calculate “tt”, hydrostatic test shell thickness (API-650, 5.6.3.2)

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5.6.3.2 The required minimum thickness of shell plates shall be the greater of the values computed by the following formulas:

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td tt D H

G CA Sd St

is the design shell thickness, in inches; is the hydrostatic test shell thickness, in inches; is the nominal tank diameter, in ft (see 5.6.1.1, Note 1); is the design liquid level, in ft: is the height from the bottom of the course under consideration to the top of the shell including the top angle, if any; to the bottom of any overflow that limits the tank filling height; or to any other level specified by the Purchaser, restricted by an internal floating roof, or controlled to allow for seismic wave action, is the design specific gravity of the liquid to be stored, as specified by the Purchaser; is the corrosion allowance, in inches, as specified by the Purchaser (see 5.3.2); is the allowable stress for the design condition, in lbf/in.2 (see 5.6.2.1); is the allowable stress for the hydrostatic test condition, in lbf/in.2 (see 5.6.2.2).

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A. The inspector should have the knowledge and skills required to review a Procedure Qualification Record and a Welding Procedure Specification or to answer questions requiring the same level of knowledge and skill. Questions covering the specific rules of Section IX will be limited in complexity and scope to the SMAW and SAW welding processes.

1. Questions will be based on: a) No more than one process b) Filler metals limited to one c) Essential, non-essential, variables only will be covered d) Number, type, and results of mechanical tests e) Base metals limited to P1 f) Additional essential variables required by API-650 or API-653

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9.2 Qualification of Welding Procedures 9.2.1 General Requirements 9.2.1.1 The erection Manufacturer and the fabrication Manufacturer if other than the erection Manufacturer, shall prepare welding procedure specifications and shall perform tests documented by procedure qualification records to support the specifications, as required by Section IX of the ASME Code and any additional provisions of this standard. If the Manufacturer is part of an organization that has, to the Purchaserâ&#x20AC;&#x2122;s satisfaction, established effective operational control of the qualification of welding procedures and of welder performance for two or more companies of different names, then separate welding procedure qualifications are not required, provided all other requirements of 9.2, 9.3, and Section IX of the ASME Code are met. Welding procedures for ladder and platform assemblies, handrails, stairways, and other miscellaneous assemblies, but not their attachments to the tank, shall comply with either AWS D1.1, AWS D1.6, or Section IX of the ASME Code, including the use of standard WPSs.

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9.2.1.2 The welding procedures used shall produce weldments with the mechanical properties required by the design.

9.2.1.3 Material specifications listed in Section 4 of this standard but not included in Table QW-422 of Section IX of the ASME Code shall be considered as P-No. 1 material with group numbers assigned as follows according to the minimum tensile strength specified: a) less than 485 MPa (70 ksi)- Group 1; b) equal to or greater than 485 MPa (70 ksi) but less than 550 MPa (80 ksi)Group 2; c) equal to or greater than 550 MPa (80 ksi)â&#x20AC;&#x201D;Group 3.

Separate welding procedures and performance qualifications shall be conducted for A841M/A841 material.

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9.2.1.4 Welding variables (including supplementary essential variables when impact tests are required by 9.2.2), as defined by QW-250 of Section IX of the ASME Code, shall be used to determine the welding procedure specifications and the procedure qualification records to be instituted. In addition, when impact tests of the heat-affected zone are required, the heat-treated condition of the base material shall be a supplementary essential variable. Plates produced by the controlled-rolled process are not to be considered as having received any heat treatment. If a protective coating has been applied to weld edge preparations, the coating shall be included as an essential variable of the welding procedure specification, as required by 7.2.1.9.

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9.2.2 Impact Tests 9.2.2.1 Impact tests for the qualification of welding procedures shall comply with the applicable provisions of 4.2.9 and shall be made at or below the design metal temperature.

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9.2.2.2 When impact testing of a material is required by 4.2.9, 4.2.10, or 4.5.4 impact tests of the heat-affected zone shall be made for all machine, automatic, and semiautomatic welding procedures.

9.2.2.3 For all materials to be used at a design metal temperature below 10째C (50째F), the qualification of the welding procedure for vertical joints shall include impact tests of the weld metal. If vertical joints are to be made by a machine, automatic, or semiautomatic process, impact tests of the heataffected zone shall also be made.

9.2.2.4 When the design metal temperature is below -7째C (20째F), impact tests of the weld metal shall be made for all procedures used for welding the components listed in 4.2.10.1, for welding attachments to these components, and for fabricating shell nozzles and manholes from pipe and forgings listed in 4.5.

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9.2.2.5 Impact tests shall show minimum values for acceptance in accordance with 4.2.9.3 and the following: a) for P-No. 1, Group 1, materials- 0 J (15 ft-lbf), average of three specimens; b) for P-No. 1, Group 2, materials- 27 J (20 ft-lbf), average of three specimens; c) for P-No. 1, Group 3, materials- 34 J (25 ft-lbf), average of three specimens.

For shell plates thicker than 40 mm (1½ in.), these values shall be increased by 7J (5 ft-lbf) for each 13 mm ( ½ in.) over 40 mm (1½ in.)

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9.2.2.6 Weld-metal impact specimens shall be taken across the weld with one face substantially parallel to and within 1.5 mm (1/16 in.) of the surface of the material. The notch shall be cut normal to the original material surface and with the weld metal entirely within the fracture zone.

9.2.2.7 Heat-affected-zone impact specimens shall be taken across the weld and as near the surface of the material as is practicable. Each specimen shall be etched to locate the heat-affected zone, and the notch shall be cut approximately normal to the original material surface and with as much heataffected-zone material as possible included in the fracture zone.

9.2.2.8 Production welding shall conform to the qualified welding procedure, but production-weld test plates need not be made.

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C. API-650 and API-653: General welding requirements: 1. API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for welding in API-650, Section 9 and other rules for welding in API-650 such as those for: a) typical joints and definitions b) weld sizes c) restrictions on joints d) maximum allowable reinforcement e) inspection requirements

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III. NONDESTRUCTIVE EXAMINATION ASME Section V, Nondestructive Examination NOTE: The examination will cover only the main body of each referenced Article, except as noted: F. API-650 and API-653: General nondestructive examination requirements: 1. API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for NDE in API650, Section 8.

2. API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction: The inspector should be familiar with and understand the general rules for NDE in API-653, Section 12

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API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction and the related portions of API Standard 650, Welded Steel Tanks for Oil Storage (NOTE: all of API-653 is applicable to the examination unless specifically excluded.)

3. The inspector should have an understanding of the requirements for performing repairs and alterations such as: a) definitions of repairs and alterations b) repairs to foundations, shell plates, welds, tank bottoms, nozzles & penetrations, roofs, seals c) knowledge of the repair/alteration material and toughness requirements d) use of unidentified materials for repairs/alterations e) hot tap requirements and procedures f) inspection and NDE requirements for repairs and alterations g) hydrostatic and leak testing requirements h) lap welded patch plates (API-653, 9-3) i) new bottoms supported by grillage API-650, Annex I, excluding calculations)

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API-653 ABOVEGROUND STORAGE TANK INSPECTOR-BOK

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BODY OF KNOWLEDGE API-653 ABOVEGROUND STORAGE TANK INSPECTOR CERTIFICATION EXAMINATION November 2015, March 2016 and July 2016 (Replaces October 2013) API Authorized Aboveground Storage Tank Inspectors must have a broad knowledge base relating to tank inspection and repair of aboveground storage tanks. The API Aboveground Storage Tank Inspector Certification Examination is designed to identify individuals who have satisfied the minimum qualifications specified in API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction.

Questions may be taken from anywhere within each document in this Body of Knowledge (BOK), unless specifically excluded herein.

In the event that specific sections of a document are listed as excluded– all other sections within that document are included.

In some cases specific paragraphs or sections, such as the example shown below, are included as an aid to the candidate. This is not intended to exclude other paragraphs.

For example: In the “Corrosion Rate and Inspection Intervals” section of this BOK (Section A, sub-section 1), it states: The Inspector must be able to calculate: a) Metal Loss (including corrosion averaging - API-653, Section 4) This means that the metal loss calculation will be found in Section 4. It does not mean that other sections in that document are excluded.

The examination consists of two parts. The closed-book part tests the candidate on knowledge and tasks requiring everyday working knowledge of API Standard 653 and the applicable reference documents. The open-book portion of the examination requires the use of more detailed information that the inspector is expected to be able to find in the documents, but would not normally be committed to memory.

REFERENCE PUBLICATIONS: A.

API Publications API Recommended Practice 571, Damage Mechanisms Affecting Equipment in Refining Industry API Recommended Practice 575, Inspection of Atmospheric and Low-Pressure Storage Tanks API Recommended Practice 577, Welding Inspection and Metallurgy API Standard 650, Welded Steel Tanks for Oil Storage API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks API Recommended Practice 652, Lining of Aboveground Petroleum Storage Tank Bottoms API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction

B.

ASME Publications

American Society of Mechanical Engineers (ASME) Boiler & Pressure Vessel Code: Section V, Nondestructive Examination Section IX, Welding and Brazing Qualifications Note: Refer to the Publications Effectivity Sheet in the application package for a list of which editions, addenda, and supplements of the reference publications are effective for your exam.

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CALCULATIONS & TABULAR EVALUATIONS FOR EVALUATING THICKNESS MEASUREMENTS, WELD SIZES, AND TANK INTEGRITY (NOTE: Paragraph references for all formulas and calculations listed here should be checked for accuracy to the edition, addenda, or supplement for the examination you plan to take per the Publication Effectivity Sheet in the API Examination Application.)

NOTE: Candidates are expected to be able to understand SI units (metric system) and the US customary units (inches, feet, PSI, etc.) and to use both system formulas.

A. Calculation questions will be oriented toward existing tanks, not new tanks. API Authorized AST Inspectors should be able to check and perform calculations included in the following categories: 1.

CORROSION RATES AND INSPECTION INTERVALS (API-575, Paragraph 7.2)

The Inspector should be able to take inspection data and determine the internal and external inspection intervals.

These calculations could be in either the “open book” or “closed book” portion of the exam. The Inspector must be able to calculate: a) b) c) d) e)

Metal Loss (including corrosion averaging – (API-653, Section 4) Corrosion Rates Remaining Life Remaining Corrosion Allowance Inspection Interval (API-653, Section 6) Remaining life (years) =

t actual - t minimum corrosion rate

[inches (millimeters) per year]

Where: t actual = t minimum =

the thickness, in inches (millimeters), recorded at the time of inspection for a given location or component. minimum allowable thickness, in inches (millimeters), for a given location or component.

Corrosion rate =

t previous =

t previous - t actual years between t actual and t previous

the thickness, in inches (millimeters), recorded at the same location as t actual measured during a previous inspection.

The formulas for performing the above calculations and rules for setting the inspection intervals may be "closedbook" during the exam. The inspector should also be able to compensate for the corrosion allowance. (Add or subtract based on requirements from the exam problem.)

2.

JOINT EFFICIENCIES

The inspector must be able to determine the joint efficiency, "E", of a tank weld. Inspector should be able to determine: a) Joint Types (API-653 Section 4, Table 4-2) b) Type and extent of radiography performed (API 653, Table 4-2, Section 12; API 650, Section 8.1, Figure 81) c) Joint efficiency by reading API-653, Table 4-2 05/15 Page 2 of 12 653_BOK_2015

Determining joint efficiency may be part of a minimum thickness or maximum fill height problem since joint efficiency, "E", is used in the formulas for determining required thickness. (API-653, 4.3.3.1) 3.

MAXIMUM FILL HEIGHT (HYDROSTATIC TESTING)

The inspector should be able to determine the maximum liquid height for a tank. To determine the height, the “t min” formula in API-653 is rearranged as follows. This formula will be provided in the exam. The inspector is NOT expected to derive this formula by using transposition. a)

Calculate the minimum allowable thickness per Section 4 of API 653 or the maximum fill height in the localized corroded area per:

 S  E  t min  H   2.6  D  G  b) Calculate the minimum allowable thickness per Section 4 of API 653 or the maximum fill height for an entire shell course per:

 S  E  t min  H  +1  2.6  D  G  4.

WELD SIZES FOR SHELL & ROOF OPENINGS

The inspector should be familiar with determining the sizes and spacing of welds for shell openings to the extent of being able to use the information in the following Figures and Tables: a) API-650, Figures 5-7a, 5-7b, 5-8, 5-9, 5-12, 5-14, 5-16, 5-17, 5-19, 5-20, 5-21 b) API-650, Tables 5-6, 5-7, 5-9 c) API-653, Figures 9-1, 9-2, 9-4, 9-5 5.

HOT TAPPING a) The Inspector should be familiar with the Hot Tapping requirements. (API-653, Paragraph 9.14) b) The inspector should be able to calculate the minimum spacing between an existing nozzle and a new hot tap nozzle. (API-653 Paragraph 9.14.3)

6.

SETTLEMENT EVALUATION

The Inspector should be able to calculate the maximum allowed settlement for the following: a) Edge Settlement (API-653 Annex B.2.3, fig. B-5) b) Bottom Settlement Near the Tank Shell (API-653, Annex B.2.4, Figures B-6, B-7, B-9 B-10, B-11, B-12, B13) c) Localized Bottom Settlement Remote from the Tank Shell (API-653, Annex B.2.5, Fig. B-8) 7.

NUMBER OF SETTLEMENT POINTS a)

The inspector should be able to calculate the number of survey points for determining tank settlement. (API653 12.5.2, Annex B, Figure B-1, Figure B-2) 05/15 Page 3 of 12

653_BOK_2015

8.

IMPACT TESTING

The inspector should understand the importance of tank materials having adequate toughness. The inspector should be able to determine: a) b) c) d) 9.

Tank design metal temperature (API-650, 4.2.9.3 & Figure 4-2) Material Group Number for a plate (API-650, Tables 4-3a and 4-3b) If impact testing is required (API-650, Figure 4-1a and 4-1b) If impact test values are acceptable (API-650, Table 4-4a and 4-4b)

EXISTING TANK SHELL - MINIMUM THICKNESS a) b) c) d) e)

Calculate “S”, allowable stress (API-653, 4.3.3.1 & 4.3.4.1) Determine “E”, Joint efficiency (API-653, 4.3.3.1, 4.3.4.1 & Tables 4-2 & 4-3) Determine “H”, liquid height (API-653, 4.3.3.1 & 4.3.4.1) Calculate- minimum acceptable thickness (API-653, 4.3.3.1 & 4.3.4.1) Calculate the thickness required for continued service (API-653, 4.3.3.1 & 4.3.4.1)

10. RECONSTRUCTED TANK SHELL - MINIMUM THICKNESS The inspector should be able to determine the minimum thickness of the shell of a reconstructed tank. The inspector should be able to: a) b) c) d)

Determine “Sd”, allowable stress for design condition (API-650, table 5-2, API-653, 8.4.2) Determine “St”, allowable stress for hydrostatic test condition (API-650, Table 5-2, API-653, 8.4.3) Calculate “td”, design shell thickness (API-650, 5.6.3.2, for tanks of 200 foot diameter and smaller) Calculate “tt”, hydrostatic test shell thickness (API-650, 5.6.3.2)

11. TANK SHELL - CORRODED AREA The inspector should be able to determine if a tank shell corroded area is acceptable for continued service. The inspector should be able to: a) b) c) d) e)

Select “t2”, minimum thickness exclusive of pits for a corroded area (API-653, 4.3.2.1.a & Figure 4-1) Calculate “L”, critical length for a corroded area (API-653, 4.3.2.1.b & Figure 4-1) Determine “t1”, average thickness for a corroded area (API-653, 4.3.2.1.c, 4.3.2.1.d, Figure 4-1) Determine “t min” for the corroded area “H”, height and “E”, joint efficiency will be based on corroded area (API-653, 4.3.3.1) Determine if tmin is acceptable (API-653, 4.3.3.1.a & .b)

12. TANK SHELL - PITTING The inspector should be able to evaluate a pitted area. The inspector should be able to: a) Calculate maximum acceptable pit depth (API-653, 4.3.2.2.a) b) Determine the maximum length of pits in any 8” vertical length (API-653, 4.3.2.2.b & Figure 4-2) 13. BOTTOM PLATE MINIMUM THICKNESS The inspector should be able to determine if the bottom thickness is acceptable for continued service. The inspector should be able to: 05/15 Page 4 of 12 653_BOK_2015

Calculate “MRT”, minimum remaining thickness at the next inspection. (API-653, 4.4.5.1) Calculate “O”, maximum period of operation. These formulas will be provided in the exam.

14. REPLACEMENT PLATES a)

The inspector should be able to determine the minimum dimensions for a replacement plate. (API-653, Figure 9-1)

15. LAP WELDED PATCH PLATES Per API-653, Paragraph 9.3 the inspector should be able to determine: a) The minimum thickness b) The minimum weld size c) The allowable size of the patch plate B. Typical code calculations and requirements that candidates will NOT be expected to know for purposes of the certification examination.

1.

2.

3.

4.

5.

6.

7.

8.

Required thickness calculations for wind, earthquake, and small internal pressures; Nozzle calculations for external loads; Flange calculations; Brazing requirements; Calculating venting requirements; Ladder, stairway, and other structural type calculations; Calculations for bottoms supported by grillage; Variable point method calculations

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II. WELDING ON ATMOSPHERIC ABOVEGROUND STORAGE TANKS ASME Section IX, Welding and Brazing Qualifications (NOTE: Candidates should be familiar with the basic requirements for welding qualifications for procedures and welding personnel contained in ASME Section IX. Brazing is NOT covered on the examination. ) A. The inspector should have the knowledge and skills required to review a Procedure Qualification Record and a Welding Procedure Specification or to answer questions requiring the same level of knowledge and skill.

Questions covering the specific rules of Section IX will be limited in complexity and scope to the SMAW and SAW welding processes.

1.

Questions will be based on: a) b) c) d) e) f)

2.

No more than one process Filler metals limited to one Essential, non-essential, variables only will be covered Number, type, and results of mechanical tests Base metals limited to P1 Additional essential variables required by API-650 or API-653

The following are specifically excluded: a) Dissimilar base metal joints b) Supplemental powdered filler metals and consumable inserts c) Special weld processes such as corrosion-resistant weld metal overlay, hard-facing overlay, and dissimilar metal welds with buttering d) Charpy impact requirements and supplementary essential variables e) Any PQR and WPS included on the examination will not include heat treatment requirements.

B. The inspector should know that the WPS must reference the applicable PQR and that the PQR must be signed and dated.

C. API-650 and API-653: General welding requirements: 1.

2.

API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for welding in API-650, Section 9 and other rules for welding in API-650 such as those for: a) typical joints and definitions b) weld sizes c) restrictions on joints d) maximum allowable reinforcement e) inspection requirements API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction: The inspector should be familiar with and understand the general rules for welding in API-653, Section 11.

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III. NONDESTRUCTIVE EXAMINATION ASME Section V, Nondestructive Examination NOTE: The examination will cover only the main body of each referenced Article, except as noted: A. Article 1, General Requirements: The inspector should be familiar with and understand: 1.

2.

3.

4.

5.

6.

The Scope of Section V, Rules for use of Section V as a referenced Code, Responsibilities of the Owner / User, and of subcontractors, Calibration, Definitions of “inspection” and “examination”, Record keeping requirements.

B. Article 2, Radiographic Examination: The inspector should be familiar with and understand: 1.

2.

3.

The Scope of Article 2 and general requirements, The rules for radiography as typically applied on butt welded AST horizontal and vertical seams such as, but not limited to: · required marking · type, selection, number, and placement of IQIs, · allowable density · control of backscatter radiation · location markers Records

C. Article 6, Liquid Penetrant Examination, Including Mandatory Appendix II: The inspector should be familiar with and understand: 1) The Scope of Article 6, 2) The general rules for applying and using the liquid penetrant method such as but not limited to: a) procedures b) contaminants c) techniques d) examination e) interpretation f) documentation g) record keeping D. Article 7, Magnetic Particle Examination (Yoke and Prod techniques only, excluding paragraphs T-765 and T-766): The inspector should be familiar with and understand the general rules for applying and using the magnetic particle method such as but not limited to: 1.

2.

The Scope of Article 7, General requirements such as but not limited to requirements for: a) procedures b) techniques (Yoke and Prod only) 05/15 Page 7 of 12

653_BOK_2015

3.

c) calibration d) examination e) interpretation Documentation and record keeping

E. Article 23, Ultrasonic Standards, Section SE–797 only – Standard practice for measuring thickness by manual ultrasonic pulse-echo contact method: The inspector should be familiar with and understand; 1.

2.

3.

The Scope of Article 23, Section SE-797, The general rules for applying and using the Ultrasonic method The specific procedures for Ultrasonic thickness measurement as contained in paragraph 7.

F. API-650 and API-653: General nondestructive examination requirements: 1.

2.

API Standard 650, Welded Steel Tanks for Oil Storage: The inspector should be familiar with and understand the general rules for NDE in API-650, Section 8.

API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction: The inspector should be familiar with and understand the general rules for NDE in API-653, Section 12

IV. PRACTICAL KNOWLEDGE - GENERAL A. The following topics may be covered: 1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

15.

16.

Organization and Certification Requirements.

Types and Definitions of Inspections.

Types Corrosion and Deterioration.

Materials and Fabrication Problems.

Welding.

Nondestructive Examination (NDE) Methods Corrosion and Minimum Thickness Evaluation.

Estimated Remaining Life.

Inspection Interval Determination and Issues Affecting Intervals.

Inspecting Relief Devices.

Inspection Safety Practices.

Inspection Records and Reports.

Repairs / Alterations.

Disassembly and Reconstruction.

Hydro Testing, Pneumatic Testing

More information relevant to each of these categories is contained in section “V. PRACTICAL KNOWLEDGE SPECIFIC” where each reference publication applicable for study for the examination has been listed with the relevant topics that may be covered on the examination.

B. Typical code requirements that candidates will NOT be expected to know for purposes of this certification examination.

1.

2.

3.

4.

5.

6.

Required thickness calculations for wind, earthquake, and small internal pressures Nozzle calculations for external loads; Flange calculations; Brazing requirements; Calculating venting requirements (API 650 5.8.5); Ladder, stairway, and other structural type calculations; 05/15 Page 8 of 12

653_BOK_2015

7.

8.

9.

10.

11.

12.

13.

14.

15.

16.

17.

18.

19.

20.

21.

22.

23.

24.

25.

26.

27.

28.

NDE requirements for eddy current, and motion radiography per ASME Section V, Article 9 Technical interpretations of API & ASME Codes and Standards Welding process requirements other than shielded metal arc welding (SMAW) and submerged arc welding (SAW) API 650, Annex D API 650, Annex E API 650, Annex F API 650, Annex G Except for G1.

API 650 Annex I Except for 1.1 and 1.2 API 650, Annex J API 650, Annex K API 650, Annex L API 650, Annex M Except for M1.

API 650 Annex O Except for O1 & O2 API 650, Annex P. API 650, Annex R API 650, Annex S Except for S1 API 650, Annex SC API 650, Annex T. API 650, Annex V. API 650, Annex W. API 650, Annex X API 650, Annex Y

V. PRACTICAL KNOWLEDGE - SPECIFIC A. Each reference publication relative to study for the examination is listed below. A list of topics, which may be covered, is listed for each publication. Some topics may be listed under more than one publication. For example; ASME Section IX is the basic document for welding requirements as referenced by API-650 and API-653. The referencing API documents contain additional welding requirements and exceptions or additions to those contained in ASME Section IX. Therefore, welding requirements may be listed under all three documents and all three documents may be listed under the general heading of “Welding on Tanks”.

API RP 571, Damage Mechanisms Affecting Fixed equipment in the Refining Industry ATTN: Inspectors are not required to memorize the definitions of terms included in Section 3 (Definitions of Terms and Abbreviations), but are expected to be familiar with the common terms and abbreviations and be able to find definitions, if needed in the solution of a test question.

Test questions will be based on the following mechanisms only: 4.2.7 - Brittle Fracture 4.2.16 - Mechanical Fatigue 4.3.2 - Atmospheric Corrosion 4.3.3 - Corrosion Under Insulation (CUI) 4.3.8 - Microbiologically Induced Corrosion (MIC) 4.3.9 - Soil Corrosion 4.3.10 – Caustic Corrosion 4.5.1 - Chloride Stress Corrosion Cracking (Cl-SCC) 4.5.3 - Caustic Stress Corrosion Cracking (Caustic Embrittlement) 5.1.1.10- Sour Water Corrosion (Acidic) 5.1.11 - Sulfuric Acid Corrosion

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API Recommended Practice 575, Inspection of Atmospheric and Low-Pressure Storage Tanks NOTE: API RP-575 is a Recommended Practice and contains many general statements that are not strict requirements.

Some questions on the examination related to RP-575 may contain phrases such as “it is best to” or “an inspector would normally” when information or statements from RP-575 are covered. In these cases it is important to be familiar with the content of RP-575 and to be able to pick the best answer of those given. All of RP-575 is applicable to the examination unless specifically excluded.

A. The inspector should have a practical understanding and be familiar with the information contained in RP-575 (excluding Annex C) as related to: 1.

2.

3.

4.

5.

6.

types of tanks covered procedures to perform internal and external inspection the types of external and internal inspections procedures to determine suitability for continued service evaluation change-of-service effects on suitability for continued service evaluation and general condition of: a) distortions, flaws, windgirders, stiffeners, welds, and nozzles b) tank bottoms c) tank foundations d) causes of corrosion, leaks, cracks, and mechanical deterioration e) auxiliary equipment. f) anchor bolts, pipe connections, ground connections g) insulation. h) shells and roofs

API RP 577, Welding Inspection and Metallurgy 1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

Definitions Welding inspection Welding processes Welding procedure Welding materials Welder qualifications Non-destructive examination Metallurgy Refinery and Petrochemical Plant Welding Issues Terminology and symbols Actions to address improperly made production welds Welding procedure review Guide to common filler metal selection Example report of RT results

API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction and the related portions of API Standard 650, Welded Steel Tanks for Oil Storage (NOTE: all of API-653 is applicable to the examination unless specifically excluded.)

A. Tank Inspection, NDE, and Testing 1.

The inspector should have a practical understanding and be familiar with the information contained in API653 related to general inspection practices such as: 05/15 Page 10 of 12

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a) types of tanks covered b) applicable inspection tasks for internal and external inspection (e.g., API Standard 653, Annex C, Checklists for Tank Inspection). c) safe working practices d) thickness and dimensional measurements and tolerances e) requirements of external and internal inspections f) frequencies and intervals for external and internal inspection g) alternatives to the required internal inspection intervals h) NDE procedures and NDE personnel qualification requirements i) types of roofs and seals and types of deterioration j) reasons for inspection and causes of deterioration of storage tanks k) procedures to check or test storage tanks for leaks l) tools and equipment for tank inspection m) failure assessment and deterioration of auxiliary equipment n) suitability for continued service. o) change-of-service effects on suitability for continued service p) evaluation of tank bottom conditions q) evaluate tank foundation conditions r) risk of failure due to brittle fracture s) evaluate the causes of corrosion, leaks, cracks, and mechanical deterioration. t) evaluate the condition of anchor bolts, pipe connections, ground connections, and insulation 2.

The inspector should have an understanding and be able to perform calculations related to: (See also previous section on â&#x20AC;&#x153;CALCULATIONS FOR EVALUATING THICKNESS MEASUREMENTS AND TANK INTEGRITYâ&#x20AC;?) a) b) c) d) e) f) g) h) i) j)

3.

actual and minimum required thickness for shell plates maximum allowable fill height required thickness for hydrotesting and for elevated temperatures evaluation of corroded areas and pits on shell plates t min, corrosion rate, inspection interval and remaining corrosion allowance distortions, flaws, welds, and nozzles. minimum thickness for tank bottoms and annular plate rings and shell rings evaluate the effects of tank bottom settlement and acceptable limits evaluate the condition of tank shells and roofs. weld size at roof-to-shell and bottom-to-shell junctions per design requirements

The inspector should have an understanding of the requirements for performing repairs and alterations such as: a) b) c) d) e) f) g) h) i)

definitions of repairs and alterations repairs to foundations, shell plates, welds, tank bottoms, nozzles & penetrations, roofs, seals knowledge of the repair/alteration material and toughness requirements use of unidentified materials for repairs/alterations hot tap requirements and procedures inspection and NDE requirements for repairs and alterations hydrostatic and leak testing requirements lap welded patch plates (API-653, 9-3) new bottoms supported by grillage API-650, Annex I, excluding calculations)

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4.

The inspector should have an understanding of the requirements for recording the inspection data and records related to inspection, repairs, and alterations such as: a) nameplate requirements b) record-keeping requirements c) reports for inspection, repair and alterations

API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks NOTE: Only Sections 1, 2, 3, 4, 5, 6, 8, and 11 will be covered on the examination.

A. The inspector should have a practical understanding and be familiar with the information contained in RP-651 related to: 1.

2.

3.

4.

Corrosion of Aboveground Steel Storage Tanks Determination of Need for Cathodic Protection Methods of Cathodic Protection for Corrosion Control Operation and Maintenance of Cathodic Protection Systems

B. Information contained in RP-651 which the inspector will not be examined on: 1.

2.

design of cathodic protection systems sources, detection, and control of interference currents

API Recommended Practice 652, Lining of Aboveground Petroleum Storage Tank Bottoms A. The inspector should have a practical understanding and be familiar with the information contained in RP-652 related to: 1.

2.

3.

4.

5.

6.

types of tank bottom linings and advantage and disadvantages of each considerations for recommending tank bottom linings causes of tank bottom lining failures types of tank bottom lining materials surface preparation requirements for the installation of tank bottom linings issues affecting the application of a tank bottom lining

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API-653 ABOVEGROUND STORAGE TANK Publications Effectivity Sheet

Charlie Chong/ Fion Zhang

API 653 Exam Administration -- Publications Effectivity Sheet FOR: November 2015, March 2016 and July 2016 Listed below are the effective editions of the publications required for this exam for the date(s) shown above.

Please be advised that API and ASME documents and publications are copyrighted materials. Reproducing these documents without API permission is illegal. 

API Recommended Practice 571, Damage Mechanisms Affecting Fixed Equipment in the Refining Industry,

Second Edition, April 2011 ATTENTION: Only the following sections / mechanisms from RP 571 are included on the exam: Section 3, Definitions Par. 4.2.7 Brittle Fracture 4.2.16 Mechanical Fatigue 4.3.2 Atmospheric Corrosion 4.3.3 Corrosion Under insulation (CUI) 4.3.8 Microbiologically Induced Corrosion (MIC) 4.3.9 Soil Corrosion 4.3.10 Caustic Corrosion 4.5.1 Chloride Stress Corrosion Cracking (Cl-SCC) 4.5.3 Caustic Stress Corrosion Cracking (Caustic Embrittlement) 5.1.1.10 Sour Water Corrosion (Acidic) 5.1.1.11 Sulfuric Acid Corrosion 

API Recommended Practice 575, Inspection of Atmospheric and Low-Pressure Storage Tanks, Third Edition, April 2014



API Recommended Practice 577 – Welding Inspection and Metallurgy, Second Edition, December 2013



API Standard 650, Welded Tanks for Oil Storage, Twelfth Edition, March 2013 with Addendum 1 (September 2014), Errata 1 (July 2013), and Errata 2 (December 2014).



API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks, Fourth Edition, September 2014.



API Recommended Practice 652, Lining of Aboveground Petroleum Storage Tank Bottoms, Fourth Edition, September 2014



API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction, Fifth Edition, November 2014.



American Society of Mechanical Engineers (ASME), Boiler and Pressure Vessel Code, 2013 Edition i. ASME Section V, Nondestructive Examination, Articles 1, 2, 6, 7 and 23 (section SE-797 only) ii. Section IX, Welding and Brazing Qualifications (Welding Only)

___________________________________________________________________________ Please ensure you obtain authorized documents from one of API’s redistributors: Techstreet: www.techstreet.com; Phone: 1-800-699-9277 IHS Documents: www.global.ihs.com; Phone: 1-800-854-7179

653_2015_53014

http://independent.academia.edu/CharlieChong1 http://www.yumpu.com/zh/browse/user/charliechong http://issuu.com/charlieccchong

Charlie Chong/ Fion Zhang

Charlie Chong/ Fion Zhang

Charlie Chong/ Fion Zhang

Good Luck!

Charlie Chong/ Fion Zhang

Good Luck!

Charlie Chong/ Fion Zhang